Ongoing and Future Work Computed Tomography (CT) Scanning of Cores CT scanning of rock cores enable non-destructive fine scale characterization of rock cores. By calibrating the attenuation of the X-rays of samples to materials of known densities we were able to reconstruct a density/depth map of hundreds of feet of Marcellus core with millimeter resolution. CT scanning also enabled us to visualize fractures embedded within the cores, a task we are continuing to explore. Planned work will be utilizing a micro-CT scanner where we plan to evaluate pore geometries within the Marcellus and other shales. Computed Tomography (CT) Scanning of Cores CT scanning of rock cores enable non-destructive fine scale characterization of rock cores. By calibrating the attenuation of the X-rays of samples to materials of known densities we were able to reconstruct a density/depth map of hundreds of feet of Marcellus core with millimeter resolution. CT scanning also enabled us to visualize fractures embedded within the cores, a task we are continuing to explore. Planned work will be utilizing a micro-CT scanner where we plan to evaluate pore geometries within the Marcellus and other shales. Website: Customer Service: Albany, OR Fairbanks, AK Morgantown, WV Pittsburgh, PA Houston, TX 0021 – CR – 09/10 - Crandall Multi-scale and Integrated Characterization of the Marcellus Shale in the Appalachian Basin: From Microscopes to Mapping NS41B-1517 Daniel J. Soeder 1, Kalin T. McDannell 2,3, Thomas H. Mroz 1 & Dustin Crandall 2 1 National Energy Technology Lab, United States Department of Energy, Morgantown, WV, USA 2 URS/Washington Division, National Energy Technology Lab, Morgantown, WV, USA 3 Geology and Geography Department, West Virginia University, Morgantown, WV, USA ABSTRACT Historic data from the Department of Energy Eastern Gas Shale Project (ESGP) were compiled to develop a database of geochemical analyses, well logs, lithological and natural fracture descriptions from oriented core, and reservoir parameters. The nine EGSP wells were located throughout the Appalachian Basin and intercepted the Marcellus Shale from depths of 750 meters (2500 ft) to 2500 meters (8200 ft). A primary goal of this research is to use these existing data to help construct a geologic framework model of the Marcellus Shale across the basin and link rock properties to gas productivity. In addition to the historic data, x-ray computerized tomography (CT) of entire cores with a voxel resolution of 240  m and optical microscopy to quantify mineral and organic volumes was performed. Porosity and permeability measurements in a high resolution, steady-state flow apparatus are also planned. Earth Vision software was utilized to display and perform volumetric calculations on individual wells, small areas with several horizontal wells, and on a regional basis. The results indicate that the lithologic character of the Marcellus Shale changes across the basin. Gas productivity appears to be influenced by the properties of the organic material and the mineral composition of the rock, local and regional structural features, the current state of in-situ stress, and lithologic controls on the geometry of induced fractures during stimulations. The recoverable gas volume from the Marcellus Shale is variable over the vertical stratigraphic section, as well as laterally across the basin. The results from this study are expected to help improve the assessment of the resource, and help optimize the recovery of natural gas. ABSTRACT Historic data from the Department of Energy Eastern Gas Shale Project (ESGP) were compiled to develop a database of geochemical analyses, well logs, lithological and natural fracture descriptions from oriented core, and reservoir parameters. The nine EGSP wells were located throughout the Appalachian Basin and intercepted the Marcellus Shale from depths of 750 meters (2500 ft) to 2500 meters (8200 ft). A primary goal of this research is to use these existing data to help construct a geologic framework model of the Marcellus Shale across the basin and link rock properties to gas productivity. In addition to the historic data, x-ray computerized tomography (CT) of entire cores with a voxel resolution of 240  m and optical microscopy to quantify mineral and organic volumes was performed. Porosity and permeability measurements in a high resolution, steady-state flow apparatus are also planned. Earth Vision software was utilized to display and perform volumetric calculations on individual wells, small areas with several horizontal wells, and on a regional basis. The results indicate that the lithologic character of the Marcellus Shale changes across the basin. Gas productivity appears to be influenced by the properties of the organic material and the mineral composition of the rock, local and regional structural features, the current state of in-situ stress, and lithologic controls on the geometry of induced fractures during stimulations. The recoverable gas volume from the Marcellus Shale is variable over the vertical stratigraphic section, as well as laterally across the basin. The results from this study are expected to help improve the assessment of the resource, and help optimize the recovery of natural gas. 40 image slices from over 30,000 individual scans 3.5 in 1 ft 3D digital reconstruction of CT scanned core CT scan of core from ≈7467 feet. 3 ft EGSP Data and Availability EGSP to GIS Results & Conclusions The ability to extend the use of historic data by utilizing mapping and synergistic techniques. CT scanning and microscopy enable small scale views that give insight into the structure of different features. Maps and modeling of the basin can be further developed as work progresses to visually aid in answering questions about the geology and material properties of the rocks and show how and if they vary, possibly allowing for a lithofacies- based estimate on gas production. Results & Conclusions The ability to extend the use of historic data by utilizing mapping and synergistic techniques. CT scanning and microscopy enable small scale views that give insight into the structure of different features. Maps and modeling of the basin can be further developed as work progresses to visually aid in answering questions about the geology and material properties of the rocks and show how and if they vary, possibly allowing for a lithofacies- based estimate on gas production. References GIS maps compiled data from: WV GIS technical center, USGS, West Virginia Geological Survey (WVGES), and Pennsylvania Geological Survey EGSP poster section: information and maps from EIA and WVGES Acknowledgments We wish to thank Bryan Tennant, Karl Jarvis & John Landis for help with the CT scanning, imaging, and analysis and Andrew Shultz for the CFLM scanning. References GIS maps compiled data from: WV GIS technical center, USGS, West Virginia Geological Survey (WVGES), and Pennsylvania Geological Survey EGSP poster section: information and maps from EIA and WVGES Acknowledgments We wish to thank Bryan Tennant, Karl Jarvis & John Landis for help with the CT scanning, imaging, and analysis and Andrew Shultz for the CFLM scanning. Internal fractures (green) identified from CT scans 2 ½ ft Confocal laser scanning microscopy to visualize the surface topology of natural fractures within the core. Photograph of vertical fracture in core from ft EGSP WV-6 Marcellus Shale SEM-derived image of 100% carbon woody organic and pyrite nodule within Marcellus SEM-derived image of 2µm wide micro-crack within Marcellus Woody organic 10 µm Pyrite Integrating well log data into stackable GIS maps These maps were created using a compilation of data from statewide and national sources. Along with modeling done in Earth Vision mapping increases the understanding of Appalachian basin geometry and correlation with well-log data. Porosity, pore-geometries, thermal maturity, and inorganic/organic content of the Marcellus are properties that when fully evaluated can be added to these maps to further enhance the understanding of the Appalachian Basin and show how/if they vary with the geology and if they are predictable. Earth Vision modeling to visualize 3D basin structure. (constructed from data from over 2000 wells) Seven EGSP cored wells were located in West Virginia. The first five wells in the program targeted the Lower Huron Member of the Ohio Shale in southwestern West Virginia. The last two cored wells in the program focused on the older and deeper shales, the Rhinestreet Shale Member of the West Falls Formation and the Marcellus Shale of the Hamilton Group.